Outline. Queensland CO 2 Storage Atlas. Southern Bowen Basin Large north south trending foredeep located close to major emission hubs.

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1 /8/200 Outline. Atlas Scope CAGS Technical orkshop Canberra 8 th 22 nd January 200 Dr Barry Bradshaw Principal Geologist CO2 Geological Storage Solutions QUNSLAND CO 2 GOLOGICAL STORAG ATLAS RSULTS 2. Assessment results from 5 High Prospectivity basins. Summary of low prospectivity basins 4. Summary of unsuitable basins 5. Discussion of storage in depleted oil & gas fields 6. Discussion of potential for storage in unmineable coals and CBM Basin prospectivity based on ranking methodology ATLAS SCOP Queensland CO 2 Storage Atlas Aim to identify with highest possible certainty prospective basins for geological storage in onshore Queensland (6 basins). Geological assessment excludes existing resources or site economics Options assessed include: regional reservoirs (saline reservoirs & aquifers); depleted oil & gas fields; deep unmineable coal seams; and salt caverns. Greatest potential in regional reservoirs using migration assisted storage (MAS) focus of presentation. Assessed sedimentary basins classified by age High Prospectivity Areas Summary Contain at least one reservoir seal interval with demonstrated effectiveness for injection, storage and containment of CO 2 (i.e. have a total ranking score ). Twenty reservoirs from five basin areas (Bowen, Cooper, romanga, Galilee and Surat basins). Most reservoirs have either produced hydrocarbons, and/or are major groundwater aquifers. Have sufficient data sets to establish their prospectivity. ern Bowen Basin Large north south trending foredeep located close to major emission hubs. Queensland: ~94 conventional fields (OIP resources ~ 400 Bcf gas & 0 MMbbl oil) most near depleted; 5 commercial CSG fields (~450 Bcf) ern Bowen Basin western flank eastern flank Maximum potential storage area defined over western flank (Roma Shelf/unger area) where most conventional hydrocarbons are trapped. Potential geological storage area in the ern Bowen Basin (blue polygon) & locations of major emissions nodes Lacustrine mudstones from Moolayember Formation (Snake Creek Mudstone) form regional seal for the underlying Triassic fluvial sandstones (Showgrounds Sandstone & ). Potential for trapping on gently dipping western flank best quality reservoirs sourced from western cratonic province. Containment problem where regional seal pinches out. Some large faulted anticlines on eastern flank. Containment issue due to truncated, steeply dipping strata and large thrust faults. Poor reservoir quality due to proximity to eastern volcanic arc.

2 /8/200 Unit Moolayember Fm Moolayember Fm Snake Creek Mudstone Showgrounds Sandstone Bandanna Formation Bandanna Formation Black Alley Shale Tinowan Formation/ Back Creek Group ern Bowen Basin Location Maximum Thickness (m) Net pay 7 (av = 7; n =5) Net pay (av = 5; n = 2) Net pay 4 (av = 8; n = ) Net pay 8 (av = 6; n = 2) Net pay 8 (av = 7; n = 5) Reservoir Summary Information Porosity % Median 4; Max 5; n = 52 Median ; Max 7; n = 64 (md) Med 2.; Max 6,200; n = 2 Med 4; Max 9,577; n = 40 Regional/Sub Regional Seal(s) Snake Creek Mudstone Potential Trap Mechanisms Bulk Seal ffectiveness Faults through Seal shales and mudstones, generally > 00 m thick, known to seal gas accumulations C Regionally extensive mudstones (lacustrine mfs), < 50 m thick, known to seal gas accumulations C 2 2 siltstones and mudstones, > 00 m thick, known to seal gas accumulations Median ; Max 7; n = 92 Median ; Max 6; n = 7 Median 2; Max 40; n = 684 Med 0.5; Max 2,245; n = 664 Low; Median 0.6; Max 24; n = 6 Med.6; Max 9,440; n = 52 & Black Alley Shale siltstones, mudstones and tuffs, < 00 m thick Footnotes Seal Type Seal Ranking Reservoir Ranking Porosity Depth at Base Seal Adequate Total Score C C 2 2 Fail Regionally extensive shale (marine mfs), < 50 m thick, known to seal gas accumulations C reservoir units were ranked best potential units are the Showgrounds Sandstone sealed by the Snake Creek Mudstone and Tinowon Formation sealed by the Black Alley Shale. These reservoirs are well sealed but have highly variable reservoir quality. ern Bowen Basin Volumetric calculations were completed for reservoir units (Showgrounds Sandstone, Rewan Formation and Tinowan Formation). Reservoir net pay zone thicknesses from CR s and average porosity from QPD database used in calculations. Total maximum theoretical storage volume 6 Mt greatest theoretical capacity in Showgrounds Sandstone (9 Mt). Showgrounds Sandstone storage. Also shown are drainage cell interpretations and hydrocarbon fields (red circles). estern Bowen Basin Inverted extensional basin located close to major emission hubs. Queensland: conventional gas fields (OIP resources 74 Bcf) tight gas fields with recent reserves growth; 2 world class CSG fields (2925 Bcf) estern Bowen Basin } reservoir seal seal intervals Maximum potential storage areas defined over northern and southern parts of where conventional hydrocarbons are trapped. Potential geological storage area in the estern Bowen Basin (blue polygon) & locations of major emissions nodes Potential for trapping where CO 2 is injected into saddles and migrates updip into fault propagation anticlines. Series of thick regional seals formed in Late Permian marine shales; seals preserved in southern but often truncated and subaerially exposed in northern trough. Gas produced from low permeability reservoirs in Late Permian fluvial deltaic, coastal and shallow marine sandstones (Aldebaran Sandstone, Freitag Formation, Catherine Sandstone and Mantuan Formation). ern Unit Moolayember Fm Clematis Group Bandanna Fm Black Alley Shale Reservoir Summary Information Seal Ranking Reservoir Ranking Location Maximum Thickness (m) Porosity % (md) Regional/Sub Regional Seal(s) Potential Trap Mechanisms Footnotes Seal Type Bulk Seal ffectiveness Faults through Seal Porosity Depth at Base Seal Adequate Total Score shales and mudstones Truncated by Insufficient Insufficient Insufficient data Juarssic Unknown C Fail data data unconformity siltstones and mudstones, generally > 00m thick Median 9; Median 0.8; Max Gross 44 Structural C Max 25; n=24 489; n=9 Insufficient Insufficient Rewan or Insufficient data Unknown U data data? Regionally extensive shales, siltstones and tuffs (marine mfs), >00 m thick, known to seal accumulations in north ern Unit Bandanna formation Black Alley Shale (Mantuan Fm) Location Maximum Thickness (m) Reservoir Summary Information Porosity % (md) Regional/Sub Regional Seal(s) Potential Trap Mechanisms overlying units Insufficient Insufficient Insufficient extensively None None 2 2 Fail data data data eroded Regionally extensive shales, siltstones (marine mfs), coal and tuffs >00 m thick Insufficient Insufficient Gross 202 data at depths data at depths Black Alley Shale C >800m >800m Footnotes Seal Ranking Seal Type Bulk Seal ffectiveness Faults through Seal Porosity Regionally extensive siltstones, shales, >00 m thick, known to seal gas accumulations Reservoir Ranking Depth at Base Seal Adequate Total Score Catherine Sst Ingelara Fm Aldebaran Sst Aldebaran Sst Median ; Median 0.4; Gross 222 Black Alley Shale C 2 2 Fail Max 9; n=8 Max 89; n=47 Regionally extensive siltstones and shales (marine mfs), >00 m thick, known to seal accumulations in northern trough Median 2; Median 0.; Gross 47 C 2 2 Fail Max 7; n=2 Max ; n=9 Regionally extensive siltstones, shales (marine mfs), minor tuffs, >200 m thick, known to seal gas accumulations siltstones, mudstones, <00 m, known to seal accumulations in northern trough Net pay Median 4; Median.4; C 2 Fail.5 (n=) Max 20; n=9 Max 5; n=28 Ingelara Fm siltstones, shales, >00 m, known to seal gas accumulations Net pay Median ; (av=4, Median 2.; & Freitag/ C 2 2 Max 26; n=47 2 n=0) Max 90; n=02 Ingelara Fms Catherine Sst Ingelara Fm Aldebaran Sandstone Aldebaran Sandstone Cattle Creek Formation Net pay 4.4 Median 2; Peawaddy Median 0.; C (n=) Max 0; n=0 Formation Max 0.; n=8 Regionally extensive siltstones, shales (marine mfs), minor tuffs, >200 m thick, known to seal gas accumulations siltstones, sandy mudstones, <00 m, known to seal gas accumulations Net pay 20 Median ; Median.5; C (av=8, n=4) Max 27; n=59 & Ingelara Fm 4 Max 5; n=67 siltstones, shales, coal, >00 m, known to seal gas accumulations Net pay 6 Median 2; Limited data & Freitag/ C (av=22, n=5) Max 26; n=4 5 Ingelara fms siltstones, mudstones, >00 m, known to seal gas accumulations Cattle Creek Fm Cattle Creek Fm Reids Dome Beds siltstones, mudstones, >00 m, known to seal gas accumulations in northern trough Median.; Median 0; Gross 54 Max 9; C 2 2 Fail Max 8; n= n=9 mudstones >00 m, known to seal gas accumulations Cattle Creek Formation Reids Dome beds Gross 767 Median 7.6; Max 5; n=58 Median 0.2; Max 225; n=57 6 C 2 2 Fail mudstones >00 m, known to seal gas accumulations in southern trough Median 0; Median.4; Reids Dome Beds Gross 2,768 C 2 2 Fail Max 24; n=0 Max 28; n=50 & Cattle Creek Fm 9 reservoir units were assessed only high prospectivity unit is the Aldebaran Sandstone. Reservoir well sealed but highly variable, generally low permeability sandstones. Reids Dome Beds Gross 262 No reservoir quality sandstones No reservoir quality sandstones & Cattle Creek Fm 7 reservoir units were assessed low potential for reservoirs in Catherine Sandstone, Freitag Formation and Aldebaran Sandstone (generally low permeability reservoirs). Structural traps present but seals often truncated and subaerially exposed. 7 C 2 2 Fail 2

3 Regional Storage Volume stimation Data Quality Structural Surface Constraints: Reservoir Thickness Constraints: Reservoir Porosity Constraints: Reservoir Sgr Constraints: Good Good Very Good Regional Carbon Dioxide Density stimation Data Quality NB: Residual Gas Saturation storage has been approximated using unit specific storage cut offs (See Volumetric Methodology Section for discussion). Regional GA/GSQ interpretation considered likely to be accurate to within ±00m. Net pay zone thicknesses from limited field log analysis. Measured porosities from QPD database. Sgr set to 0%. Temperature Profile Constraints: Probable Temperature Profile Data from CSIRO selectively edited and final regional temperature profile estimated by GGSS. Pressure Profile Constraints: Probable Pressure Regime Data from CSIRO selectively edited and final regional pressure profile estimated by GGSS. Theoretical Storage Resource Storage Volume stimation Method: Statistical Net pay zone thicknesses from limited field log analysis. Storage efficiency factor is. Subjective stimate Accuracy: NB: Residual Gas Saturation storage has been approximated using unit specific storage cut offs (See Volumetric Methodology Section for discussion). /8/200 Aldebaran Sandstone potential storage area southern. Also shown are drainage cell interpretations and hydrocarbon fields (red circles). estern Bowen Basin Basin: estern Bowen Ranked Reservoir Unit: Aldebaran Sandstone Storage Mechanism: Residual Gas Saturation stimated theoretical carbon dioxide storage resource of the estern Bowen Aldebaran Sandstone reservoir is 00 Megatonnes Regional Storage Volume stimation Data Quality Structural Surface Constraints: Regional GA/GSQ interpretation. Reservoir Thickness Constraints: Based on net pay zone thicknesses highly variable function of facies, provenance and diagenesis. Reservoir Porosity Constraints: Measured porosities from QPD database. Reservoir Sgr Constraints: Sgr set to 0%. Regional Carbon Dioxide Density stimation Data Quality Temperature Profile Constraints: Probable Temperature Profile Data from CSIRO selectively edited and final regional temperature profile estimated by GGSS. Pressure Profile Constraints: Probable Pressure Regime Data from CSIRO selectively edited and final regional pressure profile estimated by GGSS. Theoretical Storage Resource Storage Volume stimation Method: Statistical Net pay zone thicknesses from limited field log analysis. Storage fficiency Factor is 0.6. Subjective stimate Accuracy: 7 stimated Potential Storage: 00 Megatonnes (theoretical storage resource) Volumetric calculations were completed for 4 reservoir units (Aldebaran sandstone sth ; Aldebaran Sandstone nth ; ; Catherine Sandstone). Reservoir net pay zone thicknesses from CRs & average porosity from QPD database used in calculations. Total theoretical storage volume 250 Mt. Greatest theoretical capacity in Aldebaran Sandstone over southern (00 Mt). Injectivity into low permeability reservoirs main uncertainty. Large intracratonic basin (overlies Bowen Basin) located close to major emission hubs. Queensland: ~45 fields (OIP resources ~500 Bcf gas & 50 MMbbl oil) most near depleted; 9 commercial CSG fields (~40 Bcf) Groundwater heavily utilised in populated areas. Large maximum potential storage area defined over much of basin area (regionally extensive reservoirs and seals extend over broad structural depression ideal for RGS trapping). Potential geological storage areas in the (blue polygons) & locations of major emissions nodes The Precipice, Basal vergreen, Boxvale, Hutton and Springbok (ranked 5) are the most important reservoir units in the basin. Four of these are the traditional reservoirs targeted for oil exploration and are below the regional seal units Reservoirs that ranked 2 have good reservoir quality but they are < 800 m deep. Shallow marine to lacustrine shales and siltstones from the arly Jurassic upper vergreen Formation and the Late Jurassic estbourne Formation provide regional conventional seals for CO 2 + several intraformational seals present). 2 units failed due to lack of regional seal. Regionally extensive fluvial sandstone units provide potential reservoirs throughout the basin. Precipice Sandstone reservoir map showing depth (mss) structure surface. Also shown are drainage cell interpretations and hydrocarbon fields (red circles). Basin: Surat Ranked Reservoir Unit: Precipice Sandstone Storage Mechanism: stimated Potential Storage:,289 Megatonnes (theoretical storage resource). Volumetric calculations were completed for 4 reservoir units (Precipice, Basal vergreen, Boxvale, Hutton) 22 Residual Gas Saturation stimated theoretical carbon dioxide storage resource of the Precipice Sandstone reservoir is 289 Megatonnes Reservoir net pay zone thicknesses from CR s and average porosity from QPD database used in calculations. Theoretical storage capacity using trapping totals 2,962 Mt in the evaluated reservoirs greatest capacity in Precipice Sandstone (,289 Mt). Large and relatively shallow basin remotely located from major emission hubs. No commercial hydrocarbons discovered despite ~50 years exploration current focus on CSG resources. Contains good quality groundwater resources. Several potential storage areas mapped over the northern and southern basin areas. Only regional well and seismic data available to evaluate storage potential. Galilee Basin Potential geological storage areas in the Galilee Basin (blue polygons) & locations of major emissions nodes

4 NB: Residual Gas Saturation storage has been approximated using unit specific storage cut offs (See Volumetric Methodology Section for discussion). /8/200 Galilee Basin ern Galilee Basin Nth Galilee Basin Sth Galilee Basin Main storage mechanism is migration trapping using low regional dip of strata in nth Galilee, and southwest plunging faulted ridges in sth Galilee Basin (potential fault seal breaches). Triassic & Late Permian strata from relatively continuous fluvial lacustrine reservoir seal units, and are potentially suitable for geological storage of CO₂ where they are preserved beneath the (truncated to the west). 7 reservoir units were ranked best potential units are the Clematis Sst/Rewan Fm sealed by Moolayember Formation; Betts Creek beds with unconventional Rewan Formation seal. These reservoirs have good excellent & moderate good measured porosity & permeability based on limited well data. ern Galilee Basin Galilee Basin Basin: Galilee Ranked Reservoir Unit: Clematis Sandstone/Rewan Fm Storage Mechanism: Regional Storage Volume stimation Data Quality Structural Surface Constraints: Reservoir Thickness Constraints: Reservoir Porosity Constraints: Reservoir Sgr Constraints: Poor Poor Regional Carbon Dioxide Density stimation Data Quality stimated net sandstone thickness actual reservoir pay zone likely to be less. Limited porosity measurements from QPD database. Sgr set to 0%. Residual Gas Saturation stimated theoretical carbon dioxide storage resource of the Galilee Basin Clematis Sandstone/Rewan Fm reservoir is 982 Megatonnes Regional seismic interpretation considered likely to be accurate ± 60 m. Temperature Profile Constraints: Probable Temperature Profile Data from CSIRO selectively edited and final regional temperature profile estimated by GGSS. Pressure Profile Constraints: Probable Pressure Regime Data from CSIRO selectively edited and final regional pressure profile estimated by GGSS. Theoretical Storage Resource Storage Volume stimation Method: Statistical Very limited well data over storage area. Storage efficiency factor is 0.0. Subjective s timate Accuracy: stimated Potential Storage: Poor 982 Megatonnes (theoretical storage resource) Volumetric calculations were completed for 4 reservoir units (Clematis Sst, Rewan Fm, Betts Creek beds and Colinlea Sst). 4 Not possible to define reservoir fairways or pay zones with regional well data coverage reservoir data is largely unconstrained, storage volumes should therefore be used with caution. 6 reservoir units were ranked best potential units are the Clematis/Rewan sealed by Moolayember Formation; Colinlea Sandstone sealed by Black Alley/Bandanna Fm. These reservoirs have good excellent measured porosity & permeability based on limited well data. ern Galilee Clematis Sst/Rewan Fm depth (mss) structure surface with drainage cells. Large theoretical storage volumes: ern Galilee 2,02 Mt ; ern Galilee Basin,28 Mt. Clematis Sandstone/Rewan Formation in ern Galilee has estimated capacity of 982 Mt. Seal capacity & faults through seal key uncertainty needs addressing through fully cored wells & modern seismic. Large intracratonic depocentre located very remotely from major emission hubs. Queensland: 8 conventional fields (OIP resources: ~500 Bcf gas, 0 MMbbls oil) most near depleted seal reservoir { Maximum potential storage area defined over southeastern basin area where most hydrocarbons are trapped. Potential geological storage area in the (blue polygon) & locations of major emissions nodes Gentle dip of structure towards basin flanks provides suitable conditions for RGS trapping of CO 2. Reservoirs generally tight (80% failure at depths >2400 mss) best in regional fluvial sandstones from Toolachee sealed by fluvio lacustrine Callamurra Member. 4

5 /8/200 Volumetric calculations were completed for one reservoir unit the Toolachee Formation Reservoir thickness was derived from isopach mapping (using Interpretation from Draper et al 2002) Calculated theoretical storage volume: 72 Mt 7 reservoir units were ranked best potential units are the Toolachee Fm and psilon Fm (latter not regionally extensive). Variable reservoir quality main issue. Toolachee Fm top depth structure contours (mss), isopach (m) and drainage cell areas. No estimate is made for the Patchawarra Fm but it is likely to be similar to the Toolachee Formation Large intracratonic basin remotely located from major emission hubs. Sub mature oil province in Queensland: ~80 fields (OIP resource ~00 MMbbl oil) several sub economic pools also discovered. Groundwater heavily utilised in populated areas. Very large maximum potential storage area defined over much of basin area (regionally extensive reservoirs and seals at depths >800 m BGL). Potential geological storage area in the (blue polygon) & locations of major emissions nodes Ideal components for geological storage provided by thick regionally extensive regional seal interval comprising marine shales interbedded with varying amounts of sandstone, limestone and siltstone overlying vertically stacked fluvio lacustrine to shallow marine reservoirs and intraformational seals. The presence of large anticlinal structures as well as flat shallow dipping synclines and monoclines indicate that a range of both structural and trapping mechanisms could be utilised. Illuthalla Volumetric calculations were completed for 5 reservoir units (Poolowanna Fm, Hutton Sst, Adori Sst, Hooray Sst & yandra Sst). Reservoir thickness was derived from isopach mapping (using QPD formation top data). Porosity vs depth function incorporated into calculations. 7 reservoir units were ranked 5 of these are the traditional reservoirs targeted for oil exploration and are below the regional seal units; 2 units are above the regional seal and fail due to lack of seal. Those units below the regional seal are generally characterised by moderate excellent reservoir quality. Bulk seal effectiveness of the intraformational seals (Birkhead, estbourne etc) may be limited on a regional scale is effective locally as demonstrated by the occurrence of hydrocarbon accumulations. Hutton Sandstone top depth structure contours (mss), isopach (m) and drainage cell areas The combined theoretical capacity for these reservoirs is massive (46,499 Mt) reflects the extensive nature and thickness of reservoir units. Hutton Sandstone capacity is estimated at 2,262 Mt of CO 2. 5

6 /8/200 LO PROSPCTIVITY Results: Low Prospectivity Basins UNSUITABL Results: Unsuitable Basins basins evaluated as having low prospectivity. Contain reservoir seal interval/s with uncertain effectiveness due to either limited data to evaluate their prospectivity, or high variability in the quality of reservoirs and seals. 9 unsuitable basins are known to be unprospective as their reservoirs and/or seals are all below the minimum criteria DPLTD FILDS Depleted Fields A maximum theoretical replacement volume (MTRV) calculated on original in place resources as reported by QDDDI 2008 A MTRV of 74 Mt CO 2 is estimated for 295 gas and/or oil fields and ~485 reported producing reservoir pools in Queensland However, most large fields are still producing and are unlikely to be available for CO 2 storage in the near future. Only 99 fields are either depleted or neardepleted (<5 % original 2P reserves remaining), which have a combined MTRV of 64.6 Mt CO 2 Location of oil, gas and oil and gas fields scaled by MTRV. Also shown are major emissions nodes and gas (red lines) and oil (green lines) pipelines COAL STORAG Potential Coal Storage Areas Potential storage areas defined in major coal basins (Bowen, Surat & Galilee basins) using depth cut offs of >400 m (sub economic depth for mining) and <,000 m (permeability). Storage volumes have not been calculated know that these will be unrealistically large injectivity is real issue Results show best potential is in CBM exploration sweet spots mainly an option for CBM recovery over the Comet & Dawson Valley Location of thick extensive coal measures at depths >400 and <000m (grey hatched polygons). Also shown are CSG fields and 2P resources (June 2008) Summary The greatest potential for storage is using RGS trapping in regionally extensive reservoir seal intervals rather than depleted fields or coal seams Good opportunities for geological storage are most evident in the Bowen, Cooper, romanga, Galilee and Surat basins, but: further drilling and exploration is required in many parts of these basins to fully document the quality of their storage prospectivity Queensland Government have legislation (Greenhouse Gas Storage Act 2009) that will come into effect Feb 200 Soon to have gazettal rounds in place for permits to: explore for underground storage reservoirs storage of greenhouse gases to take place Basin prospectivity based on ranking methodology ACKNOLDGMNT Queensland CO 2 Storage Atlas team John Bradshaw Barry Bradshaw Lynton Spencer Anna Liisa Lahtinen Kamal Khider Damien Ryan Jim Colwell Alfredo Chirinos Phillippa Cooke Mark oodger endy Ronda Bruce yatt Greg Tobin Karni Sudana Helen ood Kat Norman James oodger Plus QDDI team: John Draper, Jonathan Hodgkinson, Mike McKillop, Micaela Preda and Owen Dixon. 6